OM | Application of Mixed-Integer Programming Models in Shale Gas Production: The EQT Case Study

Editor’s Note: This article briefly introduces how shale gas companies use mixed-integer programming to optimize natural gas production. Results show that, compared with the original strategy, the optimized strategy significantly increases both natural gas output and the company’s net present value. I. Introduction to EQT Headquartered in Pittsburgh, Pennsylvania, EQT is the largest natural gas producer in the United States, with a history spanning 131 years. Its core businesses include shale formation exploration, natural gas production, and market delivery of natural gas. The company holds mineral rights over more than one million hectares of land across Pennsylvania, West Virginia, and Ohio. In 2017, EQT’s average daily natural gas production reached 70 million cubic meters, generating annual revenue of $3.38 billion and holding total assets nearing $30 billion. II. Background: Shale Gas Production in the Energy Sector Shale gas is natural gas trapped within shale formations. Over the past decade, it has become an increasingly vital natural gas resource in the United States—and has drawn significant global attention. In 2000, shale gas accounted for only 1% of total U.S. natural gas production; by 2010—thanks to technological advances such as hydraulic fracturing and horizontal drilling—its share had surged to over 20%. According to projections from the U.S. Energy Information Administration (EIA), shale gas will supply 46% of U.S. natural gas by 2035. Shale gas production involves vertical drilling, horizontal drilling, and hydraulic fracturing. Hydraulic fracturing injects high-pressure fracturing fluid into low-permeability geological formations, creating underground fractures that allow trapped gas to flow into the wellbore and up to the surface. With current technology, upstream operators can drill up to 40 horizontal wells from a single well pad. Shale gas wells are characterized by very high initial production—up to 280,000 cubic meters per day—but experience steep declines of 65–85% within the first year. A typical shale well may produce over half its total lifetime volume during its first year. Shale gas wells yield natural gas of varying quality, traditionally classified as “dry gas” and “wet gas.” Both consist primarily of methane, but wet gas contains substantial quantities of natural gas liquids (NGLs)—light hydrocarbons including ethane, propane, butane, pentane, and natural gasoline. End customers impose specific requirements on gas composition and heating value (typically expressed as a range). To meet these specifications, produced gas must undergo processing at facilities to remove NGLs. In simple terms, dry gas—being richer in methane—has a relatively stable heating value and can often be delivered directly to customers without further treatment. Wet gas, however, may contain up to 15% NGLs, requiring additional processing and incurring extra costs. Consequently, wet gas commands significantly higher market prices than dry gas. Moreover, dry and wet gas often coexist within the same geographic region—meaning a single shale well can produce both types simultaneously. Faced with this complexity, EQT must routinely make three key decisions: (1) which shale gas wells to develop, based on price forecasts; (2) when and how to blend dry and wet gas to satisfy customer specifications; and (3) how much to allocate toward purification and processing.

An Undervalued Trillion-Dollar Sector: Natural Gas Is Quietly Entering an Upward Cycle

• Net Debt / EBITDA: ~1.4x — now within a healthy range. Meanwhile: • Consistent dividend payments • Ongoing share repurchases III. Industry Perspective: Why Is Natural Gas at a ‘Cycle Bottom’? Key reference point: Henry Hub Natural Gas (the world’s most influential natural gas pricing benchmark) Current status: Supply overhang → depressed prices The reasons are clear: 1️⃣ The shale revolution → explosive supply growth 2️⃣ Mild winter → weak demand 3️⃣ LNG exports not yet fully ramped up Result: Natural gas prices have remained suppressed at low levels for an extended period. Yet a turning point is emerging (core logic 🔥): 1️⃣ Supply contraction has begun Low gas prices → reduced production + lower capital expenditures — classic signals of a cycle bottom. 2️⃣ LNG export capacity is poised for explosive growth • 2025: 15 Bcfd (billion cubic feet per day) • 2027: projected ≥18 Bcfd U.S. natural gas is gradually shifting toward global pricing. 3️⃣ AI-driven electricity demand (the biggest wildcard) Causal chain: AI data centers → surging electricity demand → increased natural gas-fired power generation → higher natural gas demand This implies natural gas is no longer merely a traditional energy source—it is becoming an integral part of AI infrastructure. IV. Valuation: Is It Expensive Right Now? 1️⃣ DCF Valuation (Conservative) Base-case assumptions: EQT’s production averages ~2,300 Bcfe annually from 2026–2030 (at 2025 levels), with natural decline of 8–10% per year; Henry Hub price at $3.8/MMBtu in 2026 (per EIA forecast), gradually declining to $3.0 by 2030; NGL oil prices aligned with market expectations (Brent crude at $85/barrel in 2026, $80 in 2030). Operating cost: ~$1.05 per Mcfe (2025 actual level); maintenance capex: ~$2.1 billion annually (flat vs. 2025); discount rate: 9%; long-term growth rate: 0%. Under these assumptions, the DCF-derived intrinsic value is approximately $55 per share. If gas prices remain elevated (average $5/MMBtu from 2026–2030), DCF value rises substantially; if prices remain persistently low ($2–3/MMBtu), DCF value falls sharply. 2️⃣ Relative Valuation Peer comparison (e.g., Chesapeake, Range Resources, CNX) shows 2025 EV/EBITDA multiples generally ranging between 5x and 9x. EQT’s 2025 EV/EBITDA stands at ~7–8x—slightly below peers like RRC (~8x). Its 2025 P/E ratio is ~20x. (Note: EV/EBITDA is better suited for energy and capital-intensive firms—not for light-asset internet companies.) ⚠️ Critical Insight (Must Understand) Cyclical stocks cannot be fairly assessed using static valuation metrics, because: • Low gas prices → low EBITDA → stock appears ‘expensive’ • High gas prices → high EBITDA → stock appears ‘cheap’ The correct interpretation is: Today’s ‘neutral’ valuation likely reflects a cycle bottom. V. Demand Side: Who Are EQT’s Customers?

EQT Sees Higher 2026 US Natural Gas Output on Lower Spending, CEO Says

13 hours ago

EQT plans increased 2026 natural gas production despite reduced capital spending, driven by growing global demand and new pipeline projects. The company secured a long-term LNG supply deal with Lithuania's Ignitis.

reuters

2026-09-22

EQT Sees Higher 2026 US Natural Gas Output on Lower Spending, CEO Says

EQT Sees Higher 2026 US Natural Gas Output on Lower Spending, CEO Says

FAQ